US8141636B2 - Method and system integrating thermal oil recovery and bitumen mining for thermal efficiency - Google Patents

Method and system integrating thermal oil recovery and bitumen mining for thermal efficiency Download PDF

Info

Publication number
US8141636B2
US8141636B2 US12/664,845 US66484508A US8141636B2 US 8141636 B2 US8141636 B2 US 8141636B2 US 66484508 A US66484508 A US 66484508A US 8141636 B2 US8141636 B2 US 8141636B2
Authority
US
United States
Prior art keywords
fluid
heated
heat
acceptor
steam
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Fee Related, expires
Application number
US12/664,845
Other languages
English (en)
Other versions
US20100175876A1 (en
Inventor
Brian C. Speirs
James A. Dunn
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ExxonMobil Upstream Research Co
Original Assignee
ExxonMobil Upstream Research Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by ExxonMobil Upstream Research Co filed Critical ExxonMobil Upstream Research Co
Publication of US20100175876A1 publication Critical patent/US20100175876A1/en
Assigned to EXXONMOBIL UPSTREAM RESEARCH COMPANY reassignment EXXONMOBIL UPSTREAM RESEARCH COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: IMPERIAL OIL RESOURCES LIMITED
Assigned to IMPERIAL OIL RESOURCES LIMITED reassignment IMPERIAL OIL RESOURCES LIMITED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: DUNN, JAMES A., SPEIRS, BRIAN C.
Application granted granted Critical
Publication of US8141636B2 publication Critical patent/US8141636B2/en
Expired - Fee Related legal-status Critical Current
Adjusted expiration legal-status Critical

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection

Definitions

  • the present invention relates generally to a method and system for recovering and utilizing heat produced in a thermal oil recovery operation.
  • Thermal operations for oil recovery such as steam assisted gravity drainage (SAGD) or cyclic steam stimulation (CSS), produce large quantities of low temperature waste heat.
  • SAGD steam assisted gravity drainage
  • CSS cyclic steam stimulation
  • Steam assisted gravity draining may typically involve a high temperature high pressure fluid to be sent below ground to recover oil. When the fluid returns to the surface, some of the heat has dissipated, but there still remains a large amount of low temperature waste heat that is released to the environment without further utilization.
  • Initial heating of fluid may be accomplished using natural gas, either purchased or derived from on-site sources.
  • Certain thermal operations may have no immediate heat sink available for re-using heat generated in the operation.
  • low grade waste heat generated by the operation is typically discharged to the atmosphere.
  • a conventional SAGD operation may produce in the order of 30 MW of waste heat when hot glycol (60-80° C.) produced in the operation is cooled to about 30° C. In current economic terms, this quantity of waste heat translates into approximately $5 million per year.
  • Bitumen mining operations as may be found in the oil sands in Alberta, Canada, require large quantities of low grade heat.
  • a conventional mining operation located proximal to a river a significant amount of heat is required to raise the initial river water temperature (starting at about 2-15° C.) by approximately 30-40° C. to reach the desired process temperature (about 35-45° C.).
  • Integrating thermal methods of oil recovery that produce waste heat with bitumen mining operations that require low grade heat has been found to be an effective strategy that advantageously results in significantly reduced energy use.
  • a method of recovering heat from a thermal oil recovery operation for use in a bitumen mining operation comprises accessing a heated donor fluid resulting from a thermal oil recovery operation; heating an acceptor fluid for use in a bitumen mining operation through proximal heat exchange with the heated donor fluid to produce a heated acceptor fluid; and directing the heated acceptor fluid to a bitumen mining operation.
  • a system for using heat produced in a thermal oil recovery operation to heat a fluid for a bitumen mining operation comprises a heat exchange module for transferring heat from a heated donor fluid produced in a thermal oil recovery operation to an acceptor fluid to produce a heated acceptor fluid for use in a bitumen mining operation, the heat exchange module being located proximal to the heated donor fluid; an input conduit along which the acceptor fluid flows to the heat exchange module; and an output conduit along which the heated acceptor fluid is directed from the heat exchange module to a bitumen mining operation.
  • FIG. 1 is a schematic representation of the method described herein.
  • FIG. 2 is a schematic representation of the system described herein.
  • FIG. 3 is a schematic illustration of an embodiment of an integrated heat exchange and power generation system that integrates SAGD waste heat with bitumen mining water heating.
  • FIG. 4 illustrates performance of a PRIOR ART exemplary Kalina® Cycle at a geothermal power plant located in Husavik, Iceland, provided herein as a comparative example.
  • the present invention provides a method and system integrating and re-using waste heat from oil recovery operations for mining operations.
  • Integrating thermal methods of oil recovery that produce waste heat with bitumen mining operations that require low grade heat is an effective strategy that advantageously results in significantly reduced energy use.
  • Waste heat from power cycles within a thermal oil recovery operation (for example, SAGD) can be used to preheat water or other fluids intended for mining extraction purposes in a bitumen mining operation.
  • a method of recovering heat from a thermal oil recovery operation for use in a bitumen mining operation comprises accessing a heated donor fluid resulting from a thermal oil recovery operation; heating an acceptor fluid for use in a bitumen mining operation through proximal heat exchange with the heated donor fluid to produce a heated acceptor fluid; and directing the heated acceptor fluid to a bitumen mining operation.
  • a donor fluid is any fluid that may contain excess heat for donation, which otherwise may have gone to waste or been released to atmosphere in a conventional thermal recovery operation.
  • An acceptor fluid is a fluid that is requiring heat input to be heated at the level required for its use in a bitumen mining operation.
  • a thermal oil recovery operation is any oil recovery operation wherein heat energy is imparted to the oil, including, for example: steam assisted gravity drainage (SAGD); solvent assisted SAGD; cyclic steam stimulation (CSS); combined steam and vapor extraction process (SAVEX); steam flood; steam drive; solvent assisted CSS (such as Liquid Addition to Steam for Enhanced Recovery or: LASER); or an in situ combustion operation.
  • SAGD is an exemplary type of recovery operation that will be discussed in more detail herein.
  • the heated donor fluid may comprise an aqueous solution under pressure such as, for example, a heated fluid derived from a wellbore in a SAGD operation.
  • the heated donor fluid may be the entire effluent from the well, or have undergone some constituent separation prior to use in this method.
  • the heated donor fluid may be mechanically lifted from a wellbore in a SAGD operation, for example, by using an artificial mechanical lift system such as a rod pump or rotary pump.
  • the temperature of the heated donor fluid may range from 100 to 350° C., with an exemplary range being from 150 to 220° C.
  • the additional step of deriving heat from a supplemental heat donating source for heating the acceptor fluid may be included in the method.
  • a supplemental heat donating source can be one derived from either a thermal oil recovery operation or a bitumen mining operation.
  • the supplemental heat donating source can be liquid phase blow down from a Once Through Steam Generator (OTSG); OTSG flue gas; or hot diluted bitumen.
  • OTSG Once Through Steam Generator
  • the acceptor fluid may comprise water derived from a surface source, such as a river, as is conventionally the case in bitumen mining operations. Water may be derived from any useable surface, sub-surface or process-affected source. As water can be re-used, a small or large percentage of the acceptor fluid may comprise surface or sub-surface water, ranging from 5% to 100%, depending on the water recycling capacity and requirements of the mining operation.
  • the step of heating an acceptor fluid may comprise a power generating cycle, such as an Organic Rankine Cycle (ORC), an ammonia-water system, or expansion through a steam turbine.
  • a power generating cycle such as an Organic Rankine Cycle (ORC), an ammonia-water system, or expansion through a steam turbine.
  • An exemplary ammonia-water system is the Kalina® Cycle, such as is used in some power generating operations unrelated to the oil recovery or mining industries.
  • the Kalina® system for use in the instant method may involve deriving a heated donor fluid from SAGD production at a temperature of from 150-220° C. Power can be derived when ammonia-rich vapor is directed to a turbine.
  • An acceptor fluid can be heated through heat exchange during condensation of ammonia-rich vapor.
  • a fluid produced from the heated donor fluid after heat exchange with an ammonia-water mixture, may also be of an appropriate temperature and composition to be usable in a bitumen mining operation.
  • the heated acceptor fluid, or other fluid produced from the heated donor fluid may be transported by pipeline to the mining operation.
  • a system for using heat produced in a thermal oil recovery operation to heat a fluid for a bitumen mining operation.
  • the system comprises a heat exchange module for transferring heat from a heated donor fluid produced in a thermal oil recovery operation to an acceptor fluid to produce a heated acceptor fluid for use in a bitumen mining operation.
  • the heat exchange module is located proximal to the heated donor fluid, which may mean on or near the site of the thermal recovery operation; but could also be on or near the mining site.
  • the system includes an input conduit, such as a pipeline, along which an acceptor fluid flows to the heat exchange module; and an output conduit, such as an additional pipeline, along which the heated acceptor fluid is directed from the heat exchange module to a bitumen mining operation.
  • the heat exchange module may comprise a power generating cycle, or any other module capable of direct or indirect exchange of heat between two fluids of disparate temperatures.
  • the heat exchange module is a power generating cycle that not only permits heat exchange, but also permits the generation of electrical power which may be used on site or sold.
  • the heat exchange module thus includes a condenser for condensing ammonia-rich vapor.
  • the condenser receives the acceptor fluid from the input conduit, and produces heated acceptor fluid for release to the output conduit.
  • the ammonia-rich vapor donates heat to the relatively cool acceptor fluid in order to drive the condensation process.
  • the system may be considered to include the thermal oil recovery operation, or can be considered separate from the thermal operation, for example, in those instances where a system is retro-fit to an existing operation.
  • thermal oil recovery operations resulting in excess heat being produced include steam assisted gravity drainage (SAGD); solvent assisted SAGD; cyclic steam stimulation (CSS); combined steam and vapor extraction process (SAVEX); steam flood; steam drive; solvent assisted CSS (such as Liquid Addition to Steam for Enhanced Recovery or: LASER); or in situ combustion operations.
  • SAGD steam assisted gravity drainage
  • CSS cyclic steam stimulation
  • SAVEX combined steam and vapor extraction process
  • steam flood steam drive
  • solvent assisted CSS such as Liquid Addition to Steam for Enhanced Recovery or: LASER
  • in situ combustion operations include steam assisted gravity drainage (SAGD); solvent assisted SAGD; cyclic steam stimulation (CSS); combined steam and vapor extraction process (SAVEX); steam flood; steam drive; solvent assisted CSS (such as Liquid Addition to Steam for Enhanced Recovery or: LASER); or in situ combustion operations.
  • SAGD operations hot glycol is often used to run through a closed loop of heat exchangers.
  • SAGD integration with a bitumen mining operation is one embodiment that provides a venue for use of the excess heat produced in a SAGD operation, as a result of cooling hot glycol or other fluids.
  • the excess heat can be captured and used in a bitumen mining operation, for example, to contribute to the heating of water or other fluids to the desired processing temperature.
  • the invention may be applied to the current aqueous extraction process; the temperature of the water to be heated is increased by bringing the water into proximity with the hot fluid to be cooled, so as to effect direct heat exchange.
  • a power cycle may be utilized so as to create not only a heated fluid for use in a mining operation, but also power in the form of electricity that can subsequently be used on site or sold.
  • a thermal operation can be built or adapted to channel the waste heat produced for use in heating water for bitumen mining.
  • existing SAGD operations could be retro-fit with the infrastructure required to integrate a system that captures the waste heat produced and utilizes it to heat water for a bitumen mining operation, and optionally to generate power.
  • the locations of the thermal oil recovery operation and bitumen mining operation need not be immediately adjacent to each other, provided that the two operations are appropriately located to allow transportation of fluids from one location to another with an acceptable level of heat loss.
  • practical considerations for heat recovery will include the amount of heat loss experienced over the distance a fluid is required to travel, as well as the energy and infrastructure required to permit travel of fluid over the requisite distance.
  • the amount of insulation in the pipeline used for transferring heated fluids between operations can be a factor that renders the integrated system practical when there is a long distance between operations.
  • Other unpredictable economic factors, such as fluctuations in the cost of purchased natural gas, may also be taken into consideration when considering the practical cost savings realized by the integrated system.
  • SAGD temperature may be determined or controlled for optimum reuse of produced thermal energy.
  • several parameters may be considered or incorporated to control the temperature of fluids produced in a SAGD operation. Because water makes up the majority of the produced fluid, surface pressure would be a determinant of the production temperature, rendering it similar to the saturated temperature of water. By adjusting the surface pressure at the inlet of the donor fluid acceptor fluid heat exchanger to be similar to the reservoir pressure, temperature reductions due to the thermodynamic properties of water or oil will be minimized.
  • a mechanical lift system may be used for SAGD production to transit fluids up the wellbore.
  • Exemplary mechanical lift systems include a rod pump or rotary pump.
  • a gas lift system would not be as applicable in this instance, as gas would vaporize water, absorb water vapor, and cool the production stream below the temperature that could be sustained with a different lift system.
  • Delivery pressure may be controlled so that produced fluids arrive at the operation with similar pressure to that of the bottom hole pump intake pressure. Heat loss during transit up the wellbore is relatively small, and thus a mechanical lift system that can ensure a surface pressure equivalent to reservoir pressure would result in a surface temperature only marginally different than reservoir temperature. A lower surface pressure would indicate a lower surface temperature (consistent with the saturation curve of water), but would also result in a higher fraction of water vapor at the surface than at the reservoir depth. Given these considerations, the surface temperature can be controlled to the desired range (between about 100-220° C.) to achieve the desired conditions.
  • Conventional SAGD surface facilities may be designed for a lower pressure, to support a lower temperature of around 130° C., for example. While such operations can be retro-fitted in some instances to re-use low grade heat produced, it may be desirable in other instances to design or retro-fit a plant to have a high pressure capacity so as to achieve higher temperatures (for example from or 150-220° C., or at a level in excess of 200° C.). Maintaining a consistent high pressure at the inlet to this system, comparable to that of the bottom hole pump intake pressure can result in higher efficiency.
  • Waste heat from the power generating cycle can be utilized as a heat sink to meet in whole or in part the heat requirements of a bitumen mining operation. Further, any low grade waste heat produced in the bitumen treating process may optionally be recovered and used in the method and system described.
  • Arrival temperature can thus be set by the reservoir temperature.
  • the reservoir temperature could be intentionally maintained near 200° C. This sustained high temperature can be used to generate power that is economically advantageous. Maintaining a higher fluid temperature from the SAGD operation permits more economically effective use of the waste energy produced for power generation.
  • the higher temperature can be transferred to a working fluid to generate power through any method acceptable in the geothermal industry. For example, power can be produced through use of an Organic Rankine Cycle (ORC); an ammonia-water system (Kalina® Cycle), through direct expansion through a steam turbine, etc. Further, direct transfer of heat to a fluid in need of heating is an alternative method of utilizing heat formed in the SAGD operation.
  • ORC Organic Rankine Cycle
  • Kalina® Cycle ammonia-water system
  • steam turbine etc.
  • direct transfer of heat to a fluid in need of heating is an alternative method of utilizing heat formed in the SAGD operation.
  • waste heat is converted to power for use in a bitumen mining operation, or used in direct heat exchange with the water to be heated in a bitumen mining operation, the end result is that the heat normally considered as waste heat from the power cycles of a SAGD operation can be effectively utilized as a heat source for bitumen mining.
  • FIG. 1 illustrates a flow chart of the main steps of the method of recovering heat from a thermal oil recovery operation for use in a bitumen mining operation according to an embodiment of the invention.
  • a heated donor fluid resulting from a thermal oil recovery operation is accessed.
  • an acceptor fluid is heated 14 for use in a bitumen mining operation through proximal heat exchange with the heated donor fluid to produce a heated acceptor fluid.
  • the heated acceptor fluid is directed 16 to a bitumen mining operation.
  • FIG. 2 illustrates a system for using heat produced in a thermal oil recovery operation to heat a fluid for a bitumen mining operation according to an embodiment of the invention.
  • the system comprises a heat exchange module 24 for transferring heat from a heated donor fluid produced in a thermal oil recovery operation to an acceptor fluid to produce a heated acceptor fluid for use in a bitumen mining operation.
  • the heat exchange module is located proximal to the heated donor fluid.
  • An input conduit 22 is included in the system, along which the acceptor fluid flows to the heat exchange module.
  • An output conduit 24 is included in the system. The heated acceptor fluid flows along the output conduit and is directed from the heat exchange module to a bitumen mining operation for later use.
  • FIG. 3 is a schematic illustration of an embodiment of an integrated heat exchange and power generation system. This figure focuses primarily on the heat exchange module of the system of the invention.
  • the system integrates SAGD waste heat with bitumen mining water heating through conversion of excess heat via a Kalina® Cycle process.
  • the integrated heat exchange and power generation system 300 uses fluids heated during SAGD production to warm cold water that is intended for bitumen mining operations.
  • a SAGD operation produces fluids, such as a bitumen-water mix, under pressure at a temperature of about 200° C. entering the system at input 302 . Heat from this fluid is transferred into the system 300 at exchanger 304 , which ultimately results in a cooled fluid production at output 306 .
  • the cooled fluid may go on to bitumen mining process, or may be re-used in the SAGD operation.
  • Fluids heated by the exchanger 304 are in this instance a mixture of ammonia and water. These fluids are then transferred to a separator 308 in which ammonia-rich vapor 310 and water-rich liquid 312 are separated.
  • the ammonia-rich vapor 310 is drawn off and forwarded to turbine 314 for power generation via a generator 316 , while water-rich liquid 312 is directed to a liquid exchanger 318 , after which it is re-mixed with the ammonia-rich vapor discharged from the turbine 314 to appropriate proportions selected for optimal conditions.
  • Heat from this combined flow can be recovered at a recuperator 320 .
  • cold water for example derived from lake or river water, can be heated via the cold water input 324 , and removed via the warm water output 326 for use in a bitumen mining operation.
  • the ammonia-water mixture can be pumped back to the recuperator via pump 328 , then to the liquid exchanger 318 and finally to exchanger 304 , completing the cycle.
  • Kalina® cycle using a water/ammonia mixture is exemplified here, other fluids can be used in a comparable system, such as organic solvents pentane or propane, provided the desired effect of heat transfer can be accomplished in some manner.
  • Geographical proximity of the SAGD operation and the bitumen mining operation is a consideration that can be used in the determination of optimum conditions of the system. For example, if the two operations are not immediately proximal to each other, the distance over which the water to be heated must travel between the location of the heat exchange aspect of the system and the bitumen mining can be taken into consideration to optimize the heating temperature, accounting for heat loss in transit.
  • Seasonal temperatures and conditions can also be taken into consideration to optimize the process conditions. For example, if water to be used in a bitumen mining operation is drawn from a river under winter conditions, the temperature will be near freezing, and a higher amount of heat transferred in during heat exchange in the system may be desirable. Similarly, seasonal outdoor temperatures can also be taken into consideration to determine the extent to which transferred heat may dissipate in any transit required between the heat exchange and the bitumen mining operation.
  • FIG. 4 illustrates performance of an exemplary Kalina® Cycle in more detail, intended for use in power generation.
  • the Kalina® Cycle system 400 depicted is based on a geothermal power plant located in Husavik, Iceland. While the use of heat exchange in this exemplary system in Iceland does not directly relate to oil recovery or bitumen mining operations, the premise and benefit of the system can be illustrated through the net electricity output generated.
  • a hot geothermal fluid, or brine enters the system at input 402 at a temperature of about 121° C., and at a rate of about 90 kg/s.
  • Heat from this fluid is transferred into the system 400 at exchanger 404 , which ultimately results in a cooled fluid production at output 406 .
  • the fluid emanating from the output is maintained at about 80° C., due to the requirements at this particular power plant.
  • the cooled fluid in this instance simply goes on to other external users.
  • the fluid heated by the exchanger 404 is a mixture of ammonia and water.
  • the fluid mixture in this instance having 0.81 NH 3 content at 118° C. and at a pressure of 31 bar, is transferred to a separator 408 in which ammonia-rich vapor 410 and water-rich liquid 412 are separated.
  • the ammonia-rich vapor 410 is drawn off at a rate of about 11 kg/s and forwarded to turbine 414 for power generation via a generator 416 , capable of producing about 1950 kW. While water-rich liquid 412 is directed to a liquid exchanger 418 after which water and ammonia are again re-mixed with the ammonia-rich vapor derived from the turbine 414 to appropriate proportions selected for optimal conditions. Heat from this combined flow is recovered by a recuperator 420 . As vapor is condensed to a liquid form at condenser 422 , cooling water flows through the condenser at a rate of about 173 kg/s. The cooling water absorbs heat, and may be heated from about 5° C. to about 24° C.
  • the heating of the cooling water between input 424 and output 426 is not, in this instance, used for any application relating to oil recovery or bitumen mining operations.
  • ammonia-water mixture at about 12° C. is provided to the recuperator via pump 428 , utilizing energy in an amount of approximately 130 kW.
  • the power input from hot geothermal fluid is in the range of about 15,700 kW, whereas the power output of this particular plant is about 1700 kW of electricity (net) and 14,000 kW attributable to cooling water.
  • the power generation from this power plant in Iceland can be used to illustrate that power can be generated, and provides typical values for the conditions of this plant.
  • the input temperature of 121° C. in this comparative example would be surpassed by those instances in which a higher SAGD temperature is deemed desirable, possibly at a level of up to about 200° C. Adjusting for this higher temperature, and the fluid flow rate resulting from a 15,000 bbl/d bitumen operation, it can be estimated that 6 MW of electricity could be generated for on-site use or export, according to an embodiment of the invention.
  • the Kalina® cycle is advantageously very efficient when used within the expected range of temperatures described herein. Further, an advantage of using an ammonia and water mix is that this option allows additional optimization to be realized when designing and operating the system, as the proportions of ammonia and water in the mixture can be optimized according to the actual temperature of the heat source.
  • liquid phase blow down from a Once Through Steam Generator (OTSG) in a SAGD system can be added to the power cycle to increase peak temperature and total heat input into the system.
  • OTSG flue gas heat could be captured and utilized to increase total power generation.
  • hot diluted bitumen (or “dilbit”) which may require cooling to meet pipeline specifications can result in removal of heat that can be integrated into the power cycle or used for direct heat exchange with cold extraction water.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
US12/664,845 2007-08-17 2008-06-13 Method and system integrating thermal oil recovery and bitumen mining for thermal efficiency Expired - Fee Related US8141636B2 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
CA2597881A CA2597881C (fr) 2007-08-17 2007-08-17 Procede et systeme integrant la recuperation thermique du petrole et l'exploitation miniere du bitume pour l'efficacite thermique
CA2597881 2007-08-17
PCT/US2008/007437 WO2009025693A1 (fr) 2007-08-17 2008-06-13 Procédé et système intégrant une récupération thermique d'huile et une exploitation de bitume pour avoir une efficacité thermique

Publications (2)

Publication Number Publication Date
US20100175876A1 US20100175876A1 (en) 2010-07-15
US8141636B2 true US8141636B2 (en) 2012-03-27

Family

ID=40374834

Family Applications (1)

Application Number Title Priority Date Filing Date
US12/664,845 Expired - Fee Related US8141636B2 (en) 2007-08-17 2008-06-13 Method and system integrating thermal oil recovery and bitumen mining for thermal efficiency

Country Status (3)

Country Link
US (1) US8141636B2 (fr)
CA (1) CA2597881C (fr)
WO (1) WO2009025693A1 (fr)

Cited By (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9207019B2 (en) 2011-04-15 2015-12-08 Fort Hills Energy L.P. Heat recovery for bitumen froth treatment plant integration with sealed closed-loop cooling circuit
US9546323B2 (en) 2011-01-27 2017-01-17 Fort Hills Energy L.P. Process for integration of paraffinic froth treatment hub and a bitumen ore mining and extraction facility
US9587176B2 (en) 2011-02-25 2017-03-07 Fort Hills Energy L.P. Process for treating high paraffin diluted bitumen
US9587177B2 (en) 2011-05-04 2017-03-07 Fort Hills Energy L.P. Enhanced turndown process for a bitumen froth treatment operation
US9676684B2 (en) 2011-03-01 2017-06-13 Fort Hills Energy L.P. Process and unit for solvent recovery from solvent diluted tailings derived from bitumen froth treatment
US9791170B2 (en) 2011-03-22 2017-10-17 Fort Hills Energy L.P. Process for direct steam injection heating of oil sands slurry streams such as bitumen froth
US10041005B2 (en) 2011-03-04 2018-08-07 Fort Hills Energy L.P. Process and system for solvent addition to bitumen froth
US10226717B2 (en) 2011-04-28 2019-03-12 Fort Hills Energy L.P. Method of recovering solvent from tailings by flashing under choked flow conditions
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
WO2022031321A1 (fr) * 2020-02-03 2022-02-10 Innovator Energy, LLC Systèmes et procédés de transfert de chaleur, stockage thermique et réfrigération
US11261383B2 (en) 2011-05-18 2022-03-01 Fort Hills Energy L.P. Enhanced temperature control of bitumen froth treatment process
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins
US11788798B2 (en) 2019-03-22 2023-10-17 Solvcor Technologies, Llc Systems and adjustable and high energy density thermal storage
US11796229B2 (en) 2019-03-22 2023-10-24 Solvcor Technologies. Llc Systems and methods for high energy density heat transfer

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN101608530B (zh) 2009-07-16 2012-01-25 李七妹 一种卷帘用的卷筒驱动装置的改进结构
US8833454B2 (en) 2009-07-22 2014-09-16 Conocophillips Company Hydrocarbon recovery method
CA2857131C (fr) * 2012-01-03 2018-09-11 Exxonmobil Upstream Research Company Production d'energie en utilisant un solvant non aqueux
CN103306764A (zh) * 2013-07-05 2013-09-18 重庆大学 一种带两相膨胀机的Kalina循环系统
CN104454053A (zh) * 2014-11-28 2015-03-25 天津大学 一种高效的氨水发电系统
CN106499374A (zh) * 2015-09-07 2017-03-15 中国石油天然气股份有限公司 一种使用氨气改善sagd开发效果的方法

Citations (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4212353A (en) 1978-06-30 1980-07-15 Texaco Inc. Hydraulic mining technique for recovering bitumen from tar sand deposit
GB2138840A (en) 1983-02-28 1984-10-31 Fuji Oil Co Ltd Thermal cracking of heavy hydrocarbon oils
US4487686A (en) 1983-02-28 1984-12-11 Fuji Oil Company, Ltd. Process of thermally cracking heavy hydrocarbon oils
US4554148A (en) 1983-05-20 1985-11-19 Fuji Standard Research, Inc. Process for the preparation of carbon fibers
EP0138286B1 (fr) 1983-05-20 1988-01-13 Fuji Standard Research Inc. Procédé de fabrication de brai carboné
EP0197995B1 (fr) 1984-10-03 1988-11-30 Union Carbide Corporation Procede de preparation de catalyseurs pour craquage catalytique
EP0197106B1 (fr) 1984-10-03 1989-01-18 Union Carbide Corporation Catalyseurs de craquage catalytique et procede de craquage
EP0198891B1 (fr) 1984-10-03 1989-02-15 Union Carbide Corporation Catalyseurs de craquage catalytique pour des produits d'essence a teneur en octanes elevee
US4999178A (en) 1988-12-08 1991-03-12 Bowman Melvin G Thermochemical cycle for splitting hydrogen sulfide
US20050034852A1 (en) 2001-10-11 2005-02-17 Abi Technology Heat exchange compressor
US20070095536A1 (en) 2005-10-24 2007-05-03 Vinegar Harold J Cogeneration systems and processes for treating hydrocarbon containing formations
US20070111903A1 (en) 2005-11-17 2007-05-17 General Electric Company Separatory and emulsion breaking processes

Patent Citations (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4212353A (en) 1978-06-30 1980-07-15 Texaco Inc. Hydraulic mining technique for recovering bitumen from tar sand deposit
GB2138840A (en) 1983-02-28 1984-10-31 Fuji Oil Co Ltd Thermal cracking of heavy hydrocarbon oils
US4487686A (en) 1983-02-28 1984-12-11 Fuji Oil Company, Ltd. Process of thermally cracking heavy hydrocarbon oils
US4554148A (en) 1983-05-20 1985-11-19 Fuji Standard Research, Inc. Process for the preparation of carbon fibers
EP0138286B1 (fr) 1983-05-20 1988-01-13 Fuji Standard Research Inc. Procédé de fabrication de brai carboné
EP0197995B1 (fr) 1984-10-03 1988-11-30 Union Carbide Corporation Procede de preparation de catalyseurs pour craquage catalytique
EP0197106B1 (fr) 1984-10-03 1989-01-18 Union Carbide Corporation Catalyseurs de craquage catalytique et procede de craquage
EP0198891B1 (fr) 1984-10-03 1989-02-15 Union Carbide Corporation Catalyseurs de craquage catalytique pour des produits d'essence a teneur en octanes elevee
US4999178A (en) 1988-12-08 1991-03-12 Bowman Melvin G Thermochemical cycle for splitting hydrogen sulfide
US20050034852A1 (en) 2001-10-11 2005-02-17 Abi Technology Heat exchange compressor
US20070095536A1 (en) 2005-10-24 2007-05-03 Vinegar Harold J Cogeneration systems and processes for treating hydrocarbon containing formations
US20070111903A1 (en) 2005-11-17 2007-05-17 General Electric Company Separatory and emulsion breaking processes

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
Peachy et al., "Low Carbon Futures Carbonate Triangle and Conventional Heavy Oil-Lowest GHG Production Scenarios", Mar. 31, 2007, pp. 78-79, paragraph 3.4.1.

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9546323B2 (en) 2011-01-27 2017-01-17 Fort Hills Energy L.P. Process for integration of paraffinic froth treatment hub and a bitumen ore mining and extraction facility
US9587176B2 (en) 2011-02-25 2017-03-07 Fort Hills Energy L.P. Process for treating high paraffin diluted bitumen
US10125325B2 (en) 2011-02-25 2018-11-13 Fort Hills Energy L.P. Process for treating high paraffin diluted bitumen
US9676684B2 (en) 2011-03-01 2017-06-13 Fort Hills Energy L.P. Process and unit for solvent recovery from solvent diluted tailings derived from bitumen froth treatment
US10988695B2 (en) 2011-03-04 2021-04-27 Fort Hills Energy L.P. Process and system for solvent addition to bitumen froth
US10041005B2 (en) 2011-03-04 2018-08-07 Fort Hills Energy L.P. Process and system for solvent addition to bitumen froth
US9791170B2 (en) 2011-03-22 2017-10-17 Fort Hills Energy L.P. Process for direct steam injection heating of oil sands slurry streams such as bitumen froth
US9207019B2 (en) 2011-04-15 2015-12-08 Fort Hills Energy L.P. Heat recovery for bitumen froth treatment plant integration with sealed closed-loop cooling circuit
US10226717B2 (en) 2011-04-28 2019-03-12 Fort Hills Energy L.P. Method of recovering solvent from tailings by flashing under choked flow conditions
US9587177B2 (en) 2011-05-04 2017-03-07 Fort Hills Energy L.P. Enhanced turndown process for a bitumen froth treatment operation
US11261383B2 (en) 2011-05-18 2022-03-01 Fort Hills Energy L.P. Enhanced temperature control of bitumen froth treatment process
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins
US11788798B2 (en) 2019-03-22 2023-10-17 Solvcor Technologies, Llc Systems and adjustable and high energy density thermal storage
US11796229B2 (en) 2019-03-22 2023-10-24 Solvcor Technologies. Llc Systems and methods for high energy density heat transfer
WO2022031321A1 (fr) * 2020-02-03 2022-02-10 Innovator Energy, LLC Systèmes et procédés de transfert de chaleur, stockage thermique et réfrigération

Also Published As

Publication number Publication date
US20100175876A1 (en) 2010-07-15
CA2597881A1 (fr) 2009-02-17
WO2009025693A1 (fr) 2009-02-26
CA2597881C (fr) 2012-05-01

Similar Documents

Publication Publication Date Title
US8141636B2 (en) Method and system integrating thermal oil recovery and bitumen mining for thermal efficiency
US8341960B2 (en) Multi-heat source power plant
US9394771B2 (en) Single well, self-flowing, geothermal system for energy extraction
US9181930B2 (en) Methods and systems for electric power generation using geothermal field enhancements
US5515679A (en) Geothermal heat mining and utilization
US8266908B2 (en) Multi-heat source power plant
US8474260B2 (en) System and method for producing power from thermal energy stored in a fluid produced during heavy oil extraction
US20180209305A1 (en) Integrated System for Using Thermal Energy Conversion
JPH06341368A (ja) 高圧地熱流体から電力を取得する装置及び方法
WO2011011831A1 (fr) Centrales thermiques
US20100031655A1 (en) Steam turbine closed loop geo-thermal cooling
WO2012143772A1 (fr) Centrale électrique géothermique à cycle binaire comprenant un système de récupération d'un condensat de vapeur géothermique
US8474262B2 (en) Advanced tandem organic rankine cycle
BRPI0820782B1 (pt) método, dispositivo e sistema para injeção de energia em um meio
WO2013003055A1 (fr) Centrale électrique géothermique utilisant un fluide géothermique chaud dans un appareil de récupération de chaleur à cascade
CN202349992U (zh) 吸收式热泵回收电站排汽余热并加热锅炉给水的系统
CN203655374U (zh) 基于有机朗肯循环的干热岩热能回收发电装置
CN103758593A (zh) 基于有机朗肯循环的干热岩热能回收发电装置
KR101216112B1 (ko) 저온 지열 발전 장치 및 방법
Kaplan Organic rankine cycle configurations
WO2013060340A1 (fr) Procédé de conversion de l'énergie géothermique de puits de forage en énergie électrique
CN202970815U (zh) 一种发电厂用热泵
TWM520089U (zh) 地熱發電水汽複循環系統
US10577986B2 (en) Systems and methods for improving power plant efficiency
CN211924390U (zh) 干热岩综合供能系统

Legal Events

Date Code Title Description
AS Assignment

Owner name: IMPERIAL OIL RESOURCES LIMITED, CANADA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:SPEIRS, BRIAN C.;DUNN, JAMES A.;REEL/FRAME:025824/0834

Effective date: 20071114

Owner name: EXXONMOBIL UPSTREAM RESEARCH COMPANY, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:IMPERIAL OIL RESOURCES LIMITED;REEL/FRAME:025826/0184

Effective date: 20080310

ZAAA Notice of allowance and fees due

Free format text: ORIGINAL CODE: NOA

ZAAB Notice of allowance mailed

Free format text: ORIGINAL CODE: MN/=.

STCF Information on status: patent grant

Free format text: PATENTED CASE

FPAY Fee payment

Year of fee payment: 4

MAFP Maintenance fee payment

Free format text: PAYMENT OF MAINTENANCE FEE, 8TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1552); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

Year of fee payment: 8

FEPP Fee payment procedure

Free format text: MAINTENANCE FEE REMINDER MAILED (ORIGINAL EVENT CODE: REM.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

LAPS Lapse for failure to pay maintenance fees

Free format text: PATENT EXPIRED FOR FAILURE TO PAY MAINTENANCE FEES (ORIGINAL EVENT CODE: EXP.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

STCH Information on status: patent discontinuation

Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362

FP Lapsed due to failure to pay maintenance fee

Effective date: 20240327